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510 5.8.9 Fracture mapping methods Chapter 5 Subsurface System Design Issues and Approaches 5.8.7 Rock property quantification 5.8.8 Fracturing fluid loss 5.8.10 Reservoirconnectivity Although some data are available (Batchelor, 1984), and some logging/coring analysis methods and numerical models have been developed, we still need better methods for quantifying formation properties pertinent to hydraulic fracturing and postfrac circulation. Methods are needed that include not just the nearwellbore region, but extend out as far as possible from the wells. The methods developed need to be costeffective as well as reliable. We also need to use data, gathered both in the laboratory and in the field, to validate numerical models for fluid/rock geochemical interaction. The results from current models can vary immensely. 5.8.11 Rockfluidinteractions The behavior of the reservoir during fracturing fluid injection and during circulation – and its relationship to fluid loss – is not well understood. The nature of dynamic fluid loss, and the effects of both poroelastic and thermoelastic behavior remain as issues. Specifically, it is largely unknown how thermal contraction caused by local cooling of the rock at and near fracture channels affects fluid losses and dynamic fracture propagation. While microseismic event monitoring gives us 3D, timeresolved pictures of event location and magnitude from which we infer the fractured rock volume, we do not have a quantitative understanding of how the event map relates to the flow paths that define the extent of the underground heat exchanger. More credible methods for mapping tensile fracture and shear fracture cluster geometry resulting from hydraulic stimulation are needed. Also, it may be possible to use the focal mechanisms for the events to determine which events are correlated with fluid flow. While the fractured volume may be mapped using microearthquake data, there are still issues with ensuring that production wells connect adequately with injectors through the fractured volume. Some portions of the volume may be isolated from the injector. Boundaries due to preexisting faults, fractures, and lithology changes may prevent connection or make too strong a connection with parts of the reservoir. It may be possible to improve reservoir connectivity through pressure management methods such as producing one well while injecting into another or injecting into two wells simultaneously. Geochemistry at low temperatures can be a benign factor, but as the salinity and temperature increase, it may pose difficult engineering challenges. Considerable effort is now going into the numerical modeling of coupled geochemical processes, but generally there is still a lack of data to support the verification of the models. Dissolution and precipitation problems in very high temperature EGS fields are not well understood. Conventional means of overcoming these problems by controlling pH, pressure, temperature, and the use of additives are widely known from experience at hydrothermal fields. Some laboratory studies may shed light on the processes involved; however, solutions to specific geochemical problems will have to be devised when the first commercial fields come into operation.PDF Image | Subsurface System Design Issues EGS vs. Hydrothermal Pool
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